Vertical Flow Performance Templates
8 blueprints
Deviated Well VLP Analysis
Analyze vertical lift performance in deviated and inclined wells using correlations that properly account for inclination angle. Four correlations support non-vertical wells:
Gas Well Tubing Performance
Calculate tubing performance for a gas well using single-phase gas flow correlation. Compare bottomhole pressures at different gas rates and tubing sizes to identify the optimal tubing diameter. Smaller tubing increases friction but maintains velocity above liquid loading threshold.
Multiphase Correlation Comparison
Compare pressure drop predictions from all ten industry-standard multiphase flow correlations. Understanding correlation differences helps engineers select the most appropriate method for specific well conditions.
Nodal Analysis (IPR + VLP)
Determine well operating point by intersecting the IPR curve (Vogel) with the VLP curve (Beggs-Brill multiphase tubing correlation). The node is at bottomhole — sweep flowing pressure to compute IPR rates and corresponding VLP bottomhole pressures. The operating point occurs where IPR Pwf equals VLP Pwf at the same rate.
Single-Phase Gas Well Pressure
Calculate pressure drop in single-phase gas wells using the compressible flow equations. Suitable for dry gas wells with no liquid loading.
Single-Phase Liquid Pipe Flow
Calculate pressure drop for single-phase liquid flow in pipes using the Fanning equation. Applicable to water injection, water disposal, and single-phase oil lines.
Tubing Size Selection Analysis
Compare pressure drops across different tubing sizes to optimize well production. Smaller tubing increases friction but maintains velocity for liquid lift; larger tubing reduces friction but may cause liquid loading in gas wells.
Vertical Lift Performance - Beggs & Brill
Calculate vertical lift performance (VLP) for a producing oil well using the Beggs & Brill (1973) correlation. This correlation handles multiphase (gas-liquid) flow and is applicable for any wellbore inclination.